Tieback assemblies with circulating subs for well intervention

ABSTRACT

A tieback assembly for insertion into a wellbore may include a tieback stem seal, a check valve, and a circulating sub. The tieback stem seal may be engaged into a tieback receptacle of a liner in the wellbore and may isolate an annular space of the wellbore. The circulating sub may pass kill fluid from the tieback assembly into the annular space of the wellbore. The check valve may control a flow of fluid. A method of isolating an annular space of a wellbore may include inserting a tieback assembly into the wellbore, engaging the tieback stem seal of the tieback assembly at a tieback receptacle of a liner in the wellbore, passing a kill fluid into the annular space of the wellbore, and displacing an annulus fluid in the annular space of the wellbore with the kill fluid to isolate the annular space of the wellbore.

BACKGROUND Field

The present disclosure relates to assemblies and methods for insertioninto a wellbore for the isolation of an annular space of the wellbore.

Technical Background

Oil and gas wells commonly require maintenance or repair during the lifeof the well. Well intervention generally falls into one of twocategories, light or heavy. In light well interventions, tools orsensors may be lowered into a live well while pressure is contained atthe surface (i.e., production is not stopped). In heavy wellinterventions, production of the well may be stopped prior to thenecessary maintenance or repair. Heavy well interventions may requireremoving the wellhead and other pressure barriers from the well to allowfull access to the wellbore. Accordingly, heavy well interventions mayrequire isolating the wellbore such that the required maintenance orrepair may take place.

SUMMARY

In hydrocarbon production, a wellbore may be drilled into ahydrocarbon-rich geological formation. While drilling or after thewellbore is completely drilled, a completion system may be installed tosecure the wellbore in preparation for production. The completion systemmay include a series of casings or liners cemented in the wellbore tohelp control the well and maintain well integrity.

Throughout the life of the well, maintenance or repair may be necessary.Completion system components may wear out during the life of the well,requiring maintenance or repair. For example, casings or liners maydevelop leaks, such as shallow casing leaks near the surface. As anotherexample, multiple hydrocarbon-producing regions along the wellbore mayexperience crossflow, where instead of hydrocarbons flowing to thesurface, they flow from one hydrocarbon-producing region to a secondhydrocarbon-producing region. To solve the problems associated withleaks and crossflow, well intervention may be necessary to maintain orrepair equipment. Depending on the type of well intervention, it may benecessary to kill the well (i.e., stop the well from producing bypreventing hydrocarbons from flowing into the wellbore) and isolate theannular space of the wellbore. Killing the well and isolating theannular space of the wellbore may be costly, as the well is not activelyproducing hydrocarbons. Therefore, it is important that the well bekilled quickly and efficiently such that the necessary well interventionmay take place.

Accordingly, there is an ongoing need for assemblies and methods forisolating annular spaces of wellbores to increase the efficiency of thewell intervention process. The present disclosure is directed to tiebackassemblies and methods for insertion of tieback assemblies intowellbores for isolating annular spaces of wellbores for wellintervention. More specifically, the present disclosure may allow forthe pumping of a kill fluid down boreholes and for the circulating ofthe kill fluid into the annular space where a shallow caking leaks orcrossflow is occurring. In the present disclosure tieback assembliesincluding tieback stem seals, check valves, and circulating subs may beused to increase the efficiency of isolating annular spaces of wellboresfor well intervention. As further described herein, well isolation maybe reached efficiently due to the assemblies and methods of the presentdisclosure.

According to one or more aspects of the present disclosure, a method ofisolating an annular space of a wellbore may include inserting a tiebackassembly into the wellbore. The tieback assembly may include a tiebackstem seal at a downhole end of the tieback assembly, a check valvedisposed vertically above the tieback stem seal, and a circulating subdisposed vertically above the check valve. The method may also includeengaging the tieback stem seal of the tieback assembly at a tiebackreceptacle of a liner in the wellbore, passing a kill fluid into thetieback assembly, through the circulating sub, and into the annularspace of the wellbore, and displacing an annulus fluid in the annularspace of the wellbore with the kill fluid to isolate the annular spaceof the wellbore.

According to one or more other aspects of the present disclosure, atieback assembly for insertion into a wellbore may include a tiebackstem seal, a check valve, and a circulating sub. The tieback stem sealmay define a downhole end of the tieback assembly. The circulating submay define an uphole end of the tieback assembly. The check valve may bepositioned between the tieback stem seal and the circulating sub. Thetieback stem seal may be operable to be engaged into a tiebackreceptacle of a liner in the wellbore and to isolate an annular space ofthe wellbore. The circulating sub may be operable to pass kill fluidfrom the tieback assembly, through the circulating sub, and into theannular space of the wellbore when activated. The check valve may beoperable to control a flow of fluid either through the tieback assemblyor out of the circulating sub.

Additional features and advantages of the technology described in thisdisclosure will be set forth in the detailed description which follows,and in part will be readily apparent to those skilled in the art fromthe description or recognized by practicing the technology as describedin this disclosure, including the detailed description which follows,the claims, as well as the appended drawings.

BRIEF DESCRIPTION OF THE DRAWINGS

The following detailed description of specific embodiments of thepresent disclosure can be best understood when read in conjunction withthe following drawings, where like structure is indicated with likereference numerals and in which:

FIG. 1 schematically depicts a tieback assembly engaged at a tiebackreceptacle of a liner in a wellbore, according to one or moreembodiments shown and described in this disclosure; and

FIG. 2 schematically depicts a tieback assembly, according to one ormore embodiments shown and described in this disclosure.

Reference will now be made in greater detail to various embodiments ofthe present disclosure, some embodiments of which are illustrated in theaccompanying drawings. Whenever possible, the same reference numeralswill be used throughout the drawings to refer to the same or similarparts.

DETAILED DESCRIPTION

The present disclosure is directed to tieback assemblies for insertioninto a wellbore for isolating annular spaces of wellbores for wellintervention. In particular, the tieback assemblies of the presentdisclosure may include a tieback stem seal, a check valve, and acirculating sub. Referring to FIG. 1, one embodiment of a tiebackassembly is schematically depicted. The tieback assembly may include atieback stem seal, a check valve, and a circulating sub. The tiebackstem seal may define a downhole end of the tieback assembly. Thecirculating sub may define an uphole end of the tieback assembly. Thecheck valve may be positioned between the tieback stem seal and thecirculating sub. The tieback stem seal may be operable to be engagedinto a tieback receptacle of a liner in the wellbore and to isolate anannular space of the wellbore. The circulating sub may be operable topass kill fluid from the tieback assembly, through the circulating sub,and into the annular space of the wellbore when activated. The checkvalve may be operable to control a flow of fluid either through thetieback assembly or out of the circulating sub.

The present disclosure is also directed to methods of isolating annularspaces of wellbores. Referring to FIG. 2, the methods may includeinserting a tieback assembly into the wellbore, engaging the tiebackstem seal of the tieback assembly at a tieback receptacle of a liner inthe wellbore, passing a kill fluid into the tieback assembly, throughthe circulating sub, and into the annular space of the wellbore, anddisplacing an annulus fluid in the annular space of the wellbore withthe kill fluid to isolate the annular space of the wellbore. The tiebackassembly may have any of the features as described in the precedingparagraph.

The various apparatuses and methods for isolating an annular space of awellbore may provide increased efficiency for the isolation of theannular space of the wellbore to conventional apparatuses and processesfor isolating an annular space of a wellbore. That is, the variousapparatuses and methods may allow for quick and efficient isolation ofthe annular space such that well intervention may be performed asquickly as possible. The apparatuses and methods of the presentdisclosure may allow the time that the well is killed, and therefore,not producing hydrocarbons, to be minimized.

As used throughout the present disclosure, the term “wellbore” may referto a drilled hole or borehole, including an openhole or uncased portionof the well. Borehole may refer to an inside diameter of the wellborewall (i.e., the rock face that bounds the drilled hole). As usedthroughout the present disclosure, the term “annular space” may refer tospace surrounding one cylindrical object placed inside another, such asthe space surrounding a tubular object (e.g., coiled tubing) placed in awellbore.

As used throughout the present disclosure, the term “tieback stem seal”may refer to a tieback assembly component having one or more seals thatmay be engaged into a tieback receptacle of a liner in a wellbore toisolate the liner from an annular space of the uphole casing.

As used throughout the present disclosure, the term “check valve” mayrefer to mechanical device that permits fluid to flow or pressure to actin one direction only, and/or that may selectively block flow in adirection.

As used throughout the present disclosure, the term “circulating sub”may refer to a downhole tool typically used with motors or assembliesthat may restrict the allowable fluid-circulation rates. The circulatingsub may allow a higher circulation rate to be established by opening apath to the annulus in the top section of the tool string.

As used throughout the present disclosure, the term “crossover” mayrefer to a subassembly used to enable two components (e.g., acirculating sub and a check valve or a check valve and a tieback stemseal) with different thread types, connection types, or sizes to beconnected.

Referring to FIGS. 1 and 2, a tieback assembly 100 for insertion into awellbore 200 may include a tieback stem seal 110, a check valve 120, anda circulating sub 130. The tieback stem seal 110 may define a downholeend 101 of the tieback assembly 100. The circulating sub 130 may definean uphole end 102 of the tieback assembly 100. The check valve 120 maybe positioned between the tieback stem seal 110 and the circulating sub130. The tieback stem seal 110 may be operable to be engaged into atieback receptacle 210 of a liner 220 in the wellbore 200 and to isolatean annular space 202 of the wellbore 200. The annular space 202 of thewellbore 200 may be the space between a casing 230 and any interiorcomponents, such as the tieback assembly 100. The circulating sub 130may be operable to pass kill fluid from the tieback assembly 100,through the circulating sub 130, and into the annular space 202 of thewellbore 200 when activated. The check valve 120 may be operable tocontrol a flow of fluid either through the tieback assembly 100 or outof the circulating sub 130.

The tieback stem seal 110 may include a seal 112 around the tieback stemseal 110 along the length of the tieback stem seal. The seal 112 may beoperable to isolate the annular space 202 of the wellbore 200. The seal112 may include a metal-to-metal seal or an elastomeric seal. Thetieback stem seal 110 may be any conventional or yet to be developedtieback stem seal 110. For an example of a tieback stem seal 110 and forfurther description of how a tieback stem seal 110 may operate,reference is made to U.S. Pat. No. 10,358,888 B2.

An uphole end 112 of the tieback stem seal 110 may include an outerdiameter 114 larger than an inner diameter of the tieback receptacle 210of the liner 220. Those skilled in the art may refer to the outerdiameter of the tieback stem seal 110 that is larger than the innerdiameter of the tieback receptacle 210 of the liner 220 as a “no-goprofile.” Engaging the tieback assembly 100 at the tieback receptacle210 of the liner 220 in the wellbore 200 may include inserting a lengthof the tieback stem seal 110 until the no-go profile engages the tiebackreceptacle 210 of the liner 220. This interaction between the outerdiameter 114 of the uphole end 112 of the tieback stem seal 110 and theinner diameter of the tieback receptacle 210 of the liner 220 may form ametal-to-metal seal.

The check valve 120 may be positioned directly above the tieback stemseal 110 and directly below the circulating sub 130. The check valve 120may be operable to close and prevent upward fluid flow when the tiebackstem seal 110 engaged into the tieback receptacle 210 of the liner 220in the wellbore 200. According to one or more embodiments, the checkvalve 120 may be a flapper valve. As used in the present disclosure, a“flapper valve” may refer to a type of check valve 120 having aspring-loaded plate (i.e., flapper) that may be pumped through,generally in the downhole direction, but may close if fluid attempts toflow back through the plate, generally in the uphole direction, along adrillstring or coiled tubing to the surface.

The check valve 120 may further include a ball seat 122. The ball seat122 may be operable to catch a ball 124 and direct the flow of fluid outof the circulating sub 130 and into the annular space 202 of thewellbore 200. For an example of a ball seat 122 and for furtherdescription of how a ball seat 122 may operate, reference is made toU.S. Pat. No. 6,155,350 A.

As previously discussed, the circulating sub 130 may define an upholeend 102 of the tieback assembly 100. The circulating sub 130 may beoperable to pass kill fluid from the tieback assembly 100, through thecirculating sub 130, and into the annular space 202 of the wellbore 200when activated. The circulating sub 130 may be activated by inserting ordropping a ball 124 from the surface and pumping the ball 124 down tothe ball seat 122. Once the ball 124 is set in the ball seat 122,pressure may be applied to force the ball 124 into the ball seat 122,which may activate the circulating sub 130. When the circulating sub 130is activated, a portion of kill fluid may continue to pass through thetieback assembly 100 and into the liner. The circulating sub 130 mayallow a higher circulation rate to be established by opening a path tothe annular space 202 above the liner.

The tieback assembly 100 may further include coiled tubing 150. Thecoiled tubing 150 may be in fluid communication with the surface and thetieback assembly 100. As one skilled in the art will appreciate, coiledtubing 150 may be a continuous length of pipe wound on a spool. Thecoiled tubing 150 may be attached or coupled to the tieback assembly 100such that the tieback assembly 100 may be lowered into the wellbore 200.The coiled tubing 150 may be operable to pass kill fluid from thesurface, into the tieback assembly 100, through the circulating sub 130,and into the annular space 202 of the wellbore 200.

The tieback assembly 100 may further include one or more crossovers 140to connect tieback assembly 100 components having different thread orconnection types. The one or more crossovers 140 may be positionedbetween the tieback stem seal 110 and the check valve 120, the checkvalve 120 and the circulating sub 130, or both. The one or morecrossovers 140 may have an internal void such that fluid (e.g., killfluid) may be pumped from the coiled tubing 150 and along the internalbore of the tieback assembly 100.

It is contemplated that other components or tools may be added to thetieback assembly 100 as necessary. Depending on the wellbore 200, liner,type of well intervention, etc. one skilled in the art would recognizethat additional components or tools may be beneficial to add to thetieback assembly 100 of the present disclosure.

Referring again to FIG. 2, a method of isolating the annular space 202of the wellbore 200 may include inserting the tieback assembly 100 intothe wellbore 200, engaging the tieback stem seal 110 of the tiebackassembly 100 at the tieback receptacle 210 of the liner 220 in thewellbore 200, passing a kill fluid into the tieback assembly 100,through the circulating sub 130, and into the annular space 202 of thewellbore 200, and displacing an annulus fluid in the annular space 202of the wellbore 200 with the kill fluid to isolate the annular space 202of the wellbore 200.

The method of isolating the annular space 202 of the wellbore 200 mayfurther include attaching coiled tubing 150 to the tieback assembly 100and running the tieback assembly 100 using coiled tubing 150. As oneskilled in the art will appreciate, “running” may refer to the processof lowering a component down the wellbore to a certain location. Thecoiled tubing 150 may be attached to the tieback assembly 100 prior toinserting the tieback assembly 100 into the wellbore 200. The coiledtubing 150 may fluidly couple the tieback assembly 100 to the surface,such that the kill fluid may be passed from the surface to the annularspace 202 of the wellbore 200.

As previously discussed in the present disclosure, the uphole end 112 ofthe tieback stem seal 110 may include an outer diameter 114 larger thanan inner diameter 212 of the tieback receptacle 210 of the liner 220(i.e., a no-go profile). Engaging the tieback assembly 100 at thetieback receptacle 210 of the liner 220 in the wellbore 200 may includeinserting a length of the tieback stem seal 110 until the no-go profileengages the tieback receptacle 210 of the liner 220. This couplingbetween the uphole end 112 of the tieback stem seal 110 and the tiebackreceptacle 210 of the liner 220 may create a metal-to-metal sealisolating the annular space 202 of the wellbore 200.

In one or more embodiments, the tieback stem seal 110 may include a seal110 around the tieback stem seal 110 along the length of the tiebackstem seal 110. The method of isolating the annular space 202 of thewellbore 200 may further include engaging the seal 110 with an interiorsurface 214 of the tieback receptacle 210 of the liner 220. The seal 110may include a metal-to-metal seal or an elastomeric seal.

The method of isolating the annular space 202 of the wellbore 200 mayfurther include closing the check valve 120 after engaging the tiebackstem seal 110 of the tieback assembly 100 at the tieback receptacle 210of the liner 220 in the wellbore 200. The check valve 120 may be openedwhile engaging the tieback stem seal 110 of the tieback assembly 100 atthe tieback receptacle 210 such that kill fluid may be pumped below thetieback stem seal 110 until a borehole 204 below the tieback stem seal110 is killed (i.e., isolated) and production has stopped. The ball 124may then be dropped down the wellbore 200 and into the ball seat 122,which may close the check valve 120. After closing the check valve 120,kill fluid may be bullheaded into the annular space 202 of the wellbore200. The circulating sub 130 may be operable to passing a kill fluidinto the tieback assembly 100, through the circulating sub 130, and intothe annular space 202 of the wellbore 200. As the kill fluid is passedinto the annular space 202, any annular fluid, such as hydrocarbons orair, may be displaced back into the formation. The kill fluid may be anyfluid having a density high enough to produce a hydrostatic pressure atthe point of influx in a wellbore 200 that is sufficient to shut offflow from a hydrocarbon-producing region into the wellbore 200.

In well interventions to fix a leak, it may be important to identify aleak depth prior to deploying and installing the tieback assembly 100.Similarly, in well interventions to reduce or eliminate crossflow, itmay be important to identify the depth of the multiplehydrocarbon-producing regions prior to deploying and installing thetieback assembly 100. The method of isolating the annular space 202 ofthe wellbore 200 may further include identifying the leak depth or depthof the multiple hydrocarbon-producing regions in the wellbore 200.Identifying the leak depth or depth of the multiplehydrocarbon-producing regions in the wellbore 200 may be accomplished byrunning a multi-finger caliper log, a noise log, a temperature survey,or any other known or yet to be developed method. If the leak depth ordepth of the multiple hydrocarbon-producing regions is identified to beabove the existing liner depth, the tieback assembly 100 may be used toisolate the annular space 202 of the wellbore 200 to kill the well whileisolating the leak or stopping any crossflow between the multiplehydrocarbon-producing regions.

After the annular space 202 of the wellbore 200 is isolated, the methodmay further include installing downhole plugs to isolate a reservoirsection of the wellbore 200 from a shallow leak once the annular space202 of the wellbore 200 is isolated. Alternatively or additionally, themethod may further include installing other equipment to isolatemultiple hydrocarbon-producing regions such that any crossflow may bereduced or eliminated.

One or more aspects of the present disclosure are described herein. Afirst aspect of the present disclosure may include a method of isolatingan annular space of a wellbore, the method comprising inserting atieback assembly into the wellbore. The tieback assembly may comprise atieback stem seal at a downhole end of the tieback assembly, a checkvalve disposed vertically above the tieback stem seal, and a circulatingsub disposed vertically above the check valve. The method may furthercomprise engaging the tieback stem seal of the tieback assembly at atieback receptacle of a liner in the wellbore, passing a kill fluid intothe tieback assembly, through the circulating sub, and into the annularspace of the wellbore, and displacing an annulus fluid in the annularspace of the wellbore with the kill fluid to isolate the annular spaceof the wellbore.

A second aspect of the present disclosure may include the first aspect,further comprising attaching coiled tubing to the tieback assembly priorto inserting the tieback assembly into the wellbore and running thetieback assembly using coiled tubing.

A third aspect of the present disclosure may include the second aspect,where the coiled tubing fluidly couples the tieback assembly to thesurface, such that the kill fluid may be passed from the surface to theannular space of the wellbore.

A fourth aspect of the present disclosure may include any one of thefirst through third aspects, where an uphole end of the tieback stemseal may comprise a no-go profile having an outer diameter larger thanan inner diameter of the tieback receptacle of the liner. The method mayfurther comprise engaging the tieback assembly at the tieback receptacleof the liner in the wellbore, which may comprise inserting a length ofthe tieback stem seal until the no-go profile engages the tiebackreceptacle of the liner.

A fifth aspect of the present disclosure may include the fourth aspect,where the uphole end of the tieback stem seal and the tieback receptacleof the liner may form a metal-to-metal seal isolating the annular spaceof the wellbore.

A sixth aspect of the present disclosure may include any one of thefirst through fifth aspects, where the tieback stem seal may comprise aseal around the tieback stem seal along the length of the tieback stemseal, and where the method may further comprise engaging the seal withan interior surface of the tieback receptacle of the liner.

A seventh aspect of the present disclosure may include the sixth aspect,where the seal may comprise a metal-to-metal seal or an elastomericseal.

An eighth aspect of the present disclosure may include any one of thefirst through seventh aspects, further comprising closing the checkvalve after engaging the tieback stem seal of the tieback assembly atthe tieback receptacle of the liner in the wellbore.

A ninth aspect of the present disclosure may include any one of thefirst through eighth aspects, further comprising identifying a leakdepth in the wellbore prior to inserting the tieback assembly into thewellbore and isolating the annular space of the wellbore.

A tenth aspect of the present disclosure may include any one of thefirst through ninth aspects, further comprising installing downholeplugs to isolate a reservoir section of the wellbore from a shallow leakonce the annular space of the wellbore is isolated.

An eleventh aspect of the present disclosure may include a tiebackassembly for insertion into a wellbore, the tieback assembly comprisinga tieback stem seal, a check valve, and a circulating sub. The tiebackstem seal may define a downhole end of the tieback assembly. Thecirculating sub may define an uphole end of the tieback assembly. Thecheck valve may be positioned between the tieback stem seal and thecirculating sub. The tieback stem seal may be operable to be engagedinto a tieback receptacle of a liner in the wellbore and to isolate anannular space of the wellbore. The circulating sub may be operable topass kill fluid from the tieback assembly, through the circulating sub,and into the annular space of the wellbore when activated. The checkvalve may be operable to control a flow of fluid either through thetieback assembly or out of the circulating sub.

A twelfth aspect of the present disclosure may include the eleventhaspect, where the tieback stem seal may comprise a seal around thetieback stem seal along a length of the tieback stem seal, and the sealmay be operable to isolate the annular space of the wellbore.

A thirteenth aspect of the present disclosure may include the twelfthaspect, where the seal may comprise a metal-to-metal seal or anelastomeric seal.

A fourteenth aspect of the present disclosure may include any one of theeleventh through thirteenth aspects, where the check valve may beoperable to close and prevent upward fluid flow when the tieback stemseal is engaged into the tieback receptacle of the liner in thewellbore.

A fifteenth aspect of the present disclosure may include any one of theeleventh through fourteenth aspects, where the check valve may be aflapper valve.

A sixteenth aspect of the present disclosure may include any one of theeleventh through fifteenth aspects, where the check valve may furthercomprise a ball seat operable to catch a ball and direct the flow offluid out of the circulating sub and into the annular space of thewellbore.

A seventeenth aspect of the present disclosure may include any one ofthe eleventh through sixteenth aspects, where the check valve may bepositioned directly above the tieback stem seal and directly below thecirculating sub.

An eighteenth aspect of the present disclosure may include any one ofthe eleventh through seventeenth aspects, further comprising coiledtubing in fluid communication with the surface and the tieback assembly.

A nineteenth aspect of the present disclosure may include the eighteenthaspect, where the coiled tubing may be operable to pass kill fluid fromthe surface, into the tieback assembly, through the circulating sub, andinto the annular space of the wellbore.

A twentieth aspect of the present disclosure may include any one of theeleventh through nineteenth aspects, further comprising one or morecrossovers positioned between the tieback stem seal and the check valve,the check valve and the circulating sub, or both to connect tiebackassembly components having different thread or connection types.

It is noted that one or more of the following claims utilize the term“where” as a transitional phrase. For the purposes of defining thepresent technology, it is noted that this term is introduced in theclaims as an open-ended transitional phrase that is used to introduce arecitation of a series of characteristics of the structure and should beinterpreted in like manner as the more commonly used open-ended preambleterm “comprising.”

Having described the subject matter of the present disclosure in detailand by reference to specific embodiments, it is noted that the variousdetails described in this disclosure should not be taken to imply thatthese details relate to elements that are essential components of thevarious embodiments described in this disclosure, even in cases where aparticular element is illustrated in each of the drawings that accompanythe present description. Rather, the claims appended hereto should betaken as the sole representation of the breadth of the presentdisclosure and the corresponding scope of the various embodimentsdescribed in this disclosure. Further, it will be apparent thatmodifications and variations are possible without departing from thescope of the appended claims.

What is claimed is:
 1. A method of isolating an annular space of awellbore, the method comprising: inserting a tieback assembly into thewellbore, the tieback assembly comprising a tieback stem seal at adownhole end of the tieback assembly, a check valve disposed verticallyabove the tieback stem seal, and a circulating sub disposed verticallyabove the check valve, engaging the tieback stem seal of the tiebackassembly at a tieback receptacle of a liner in the wellbore; passing akill fluid into the tieback assembly, through the circulating sub, andinto the annular space of the wellbore; and displacing an annulus fluidin the annular space of the wellbore with the kill fluid to isolate theannular space of the wellbore.
 2. The method of claim 1, furthercomprising attaching coiled tubing to the tieback assembly prior toinserting the tieback assembly into the wellbore and running the tiebackassembly using coiled tubing.
 3. The method of claim 2, where the coiledtubing fluidly couples the tieback assembly to the surface, such thatthe kill fluid may be passed from the surface to the annular space ofthe wellbore.
 4. The method of claim 1, where: an uphole end of thetieback stem seal comprises a no-go profile having an outer diameterlarger than an inner diameter of the tieback receptacle of the liner;and engaging the tieback assembly at the tieback receptacle of the linerin the wellbore comprises inserting a length of the tieback stem sealuntil the no-go profile engages the tieback receptacle of the liner. 5.The method of claim 4, where the uphole end of the tieback stem seal andthe tieback receptacle of the liner form a metal-to-metal seal isolatingthe annular space of the wellbore.
 6. The method of claim 1, where thetieback stem seal comprises a seal around the tieback stem seal alongthe length of the tieback stem seal, and where the method furthercomprises engaging the seal with an interior surface of the tiebackreceptacle of the liner.
 7. The method of claim 6, where the sealcomprises a metal-to-metal seal or an elastomeric seal.
 8. The method ofclaim 1, further comprising closing the check valve after engaging thetieback stem seal of the tieback assembly at the tieback receptacle ofthe liner in the wellbore.
 9. The method of claim 1, further comprisingidentifying a leak depth in the wellbore prior to inserting the tiebackassembly into the wellbore and isolating the annular space of thewellbore.
 10. The method of claim 1, further comprising installingdownhole plugs to isolate a reservoir section of the wellbore from ashallow leak once the annular space of the wellbore is isolated.
 11. Atieback assembly for insertion into a wellbore, the tieback assemblycomprising a tieback stem seal, a check valve, and a circulating sub,where: the tieback stem seal defines a downhole end of the tiebackassembly; the circulating sub defines an uphole end of the tiebackassembly; the check valve is positioned between the tieback stem sealand the circulating sub; the tieback stem seal is operable to be engagedinto a tieback receptacle of a liner in the wellbore and to isolate anannular space of the wellbore; the circulating sub is operable to passkill fluid from the tieback assembly, through the circulating sub, andinto the annular space of the wellbore when activated; and the checkvalve is operable to control a flow of fluid either through the tiebackassembly or out of the circulating sub.
 12. The tieback assembly ofclaim 11, where the tieback stem seal comprises a seal around thetieback stem seal along a length of the tieback stem seal, and the sealis operable to isolate the annular space of the wellbore.
 13. Thetieback assembly of claim 12, where the seal comprises a metal-to-metalseal or an elastomeric seal.
 14. The tieback assembly of claim 11, wherethe check valve is operable to close and prevent upward fluid flow whenthe tieback stem seal is engaged into the tieback receptacle of theliner in the wellbore.
 15. The tieback assembly of claim 11, where thecheck valve is a flapper valve.
 16. The tieback assembly of claim 11,where the check valve further comprises a ball seat operable to catch aball and direct the flow of fluid out of the circulating sub and intothe annular space of the wellbore.
 17. The tieback assembly of claim 11,where the check valve is positioned directly above the tieback stem sealand directly below the circulating sub.
 18. The tieback assembly ofclaim 11, further comprising coiled tubing in fluid communication withthe surface and the tieback assembly.
 19. The tieback assembly of claim18, where the coiled tubing is operable to pass kill fluid from thesurface, into the tieback assembly, through the circulating sub, andinto the annular space of the wellbore.
 20. The tieback assembly ofclaim 11, further comprising one or more crossovers positioned betweenthe tieback stem seal and the check valve, the check valve and thecirculating sub, or both to connect tieback assembly components havingdifferent thread or connection types.